| Número de publicación||US7556715 B2|
|Tipo de publicación||Concesión|
| Número de solicitud||US 10/825,230|
| Fecha de publicación||7 Jul 2009|
| Fecha de presentación||16 Abr 2004|
| Fecha de prioridad||9 Ene 2004|
|También publicado como||CA2455011A1, CA2455011C, US7914670, US20050150816, US20100006474, US20110174592|
| Número de publicación||10825230, 825230, US 7556715 B2, US 7556715B2, US-B2-7556715, US7556715 B2, US7556715B2|
| Inventores||Les Gaston, Donald Norman Madge, William Lester Strand, Ian Noble, William Nicholas Garner, Mike Lam|
| Cesionario original||Suncor Energy, Inc.|
|Exportar cita||BiBTeX, EndNote, RefMan|
|Citas de patentes (107), Otras citas (28), Citada por (6), Clasificaciones (15), Eventos legales (2) |
|Enlaces externos: USPTO, Cesión de USPTO, Espacenet|
Bituminous froth inline steam injection processing
US 7556715 B2
An inline bitumen froth steam heater system is comprised of steam injection and static mixing devices. The steam heater system heats and de-aerates an input bitumen froth without creating downstream processing problems with the bitumen froth such as emulsification or live steam entrainment. The inline bitumen froth steam heater is a multistage unit that injects and thoroughly mixes the steam with bitumen resulting in an output bitumen material having a homogenous temperature of about 190° F. The heating system conditions a superheated steam supply to obtain saturated steam at about 300° F. The saturated steam is contacted with a bitumen froth flow and mixed in a static mixer stage. The static mixers provide a surface area and rotating action that allows the injected steam to condense and transfer its heat to the bitumen froth. The mixing action and the increase in temperature of the bitumen froth results in reduction in bitumen viscosity and also allows the release of entrapped air from the bitumen froth.
1. Apparatus for heating a bitumen froth by steam, the apparatus comprising:
an injector body comprising a bitumen froth inlet for receiving the bitumen froth, a steam inlet for receiving the steam, and an injector outlet; and
a static mixer body having first and second spaced ends and forming an enclosed passageway extending between the first and second ends, wherein the first end is in communication with the injector outlet, the static mixer body supporting a plurality of baffles disposed within the enclosed passageway to effect a mixing action of the bitumen froth and the steam flowing through the enclosed passageway thereof to form a heated feed;
wherein the steam inlet is disposed to inject the steam into the injector body towards the enclosed passageway in a direction generally parallel to the a longitudinal axis of the enclosed passageway; and
wherein the apparatus is operably configured to: (a) force the bitumen froth and the steam through the injector outlet into the enclosed passageway, (b) force the bitumen froth and the steam through the enclosed passageway from the first end to the second end so as to cause the steam to contact the bitumen froth so as to form the heated feed, and (c) force all of the heated feed to exit through the second end of the static mixer body, including when the enclosed passageway is disposed parallel or about parallel to the horizontal axis.
2. The apparatus of claim 1 wherein the baffles are disposed within the static mixer body to impart a lateral, radial, tangential or circumferential directional component to the bitumen froth and the steam, the directional component changing repeatedly along a length of the enclosed passageway.
3. The apparatus of claim 1 further comprising a steam flow control valve to control a rate of supplying the steam to the steam inlet from a steam source.
4. The apparatus of claim 3 further comprising a first temperature transmitter disposed to measure a temperature of the heated feed exiting the enclosed passageway of the static mixer, wherein steam flow control valve is responsive to the measured temperature of the heated feed.
5. The apparatus of claim 1 further comprising a steam flow pressure control valve to control a pressure of the steam supplied to the steam inlet from a steam source.
6. The apparatus of claim 5 further comprising a pressure transmitter disposed to measure the pressure of the steam supplied from the steam flow pressure control valve, wherein the steam flow pressure control valve is operative to maintain the steam supplied to the steam inlet at a predetermined pressure in response to the measured pressure of the steam supplied from the steam flow pressure control valve.
7. The apparatus of claim 1
a condensate source and a steam source;
a condensate mixer operably configured to mix a condensate from the condensate source with the steam from the steam source for modulating a temperature of the steam supplied to the steam inlet; and
a condensate flow control valve to control a supply of the condensate to the condensate mixer.
8. The apparatus of claim 7 further comprising a second temperature transmitter disposed to measure the temperature of the steam supplied to the steam inlet and relay a representation of the measured temperature of the steam to the condensate flow control valve, wherein the condensate flow control valve is operative to control the supply of the condensate to the steam supplied to the steam inlet.
9. The apparatus of claim 1 wherein the steam supplied to the steam inlet comprises saturated steam.
10. The apparatus of claim 9 wherein the steam supplied to the steam inlet has a temperature of about 300° F. and a pressure of about 90 psi.
11. The apparatus of claim 9 wherein the heated feed has a substantially uniform temperature.
12. The apparatus of claim 11 wherein the substantially uniform temperature is about 190° F.
13. Apparatus for heating a bitumen froth by steam, the apparatus comprising:
an injector body comprising walls defining a chamber of the injector body, a first injector inlet for introducing the bitumen froth having a bitumen froth flow into the chamber, a second injector inlet for introducing the steam having a steam flow into the chamber, and an injector outlet, wherein the second injector inlet is configured for introducing steam; and
a static mixer body comprising:
a mixer inlet and a mixer outlet, the static mixer body forming an enclosed passageway extending between the mixer inlet and the mixer outlet, the mixer inlet being in fluid communication with the injector outlet for receiving the bitumen froth and the steam; and
mixing means for mixing the bitumen froth and the steam flowing through the enclosed passageway of the static mixer body to form a heated feed;
wherein the injector body and the static mixer body are operably configured to: (a) force the bitumen froth and the steam through the enclosed passageway from the mixer inlet to the mixer outlet so as to cause the steam to contact the bitumen froth and form the heated feed, and (b) force all of the heated feed to exit through the mixer outlet, including when the enclosed passageway is disposed parallel or about parallel to the horizontal axis.
14. The apparatus of claim 13 wherein the mixing means impart a lateral, radial, tangential or circumferential directional component to the bitumen froth and the steam, the directional component changing repeatedly along a length of the enclosed passageway.
15. The apparatus of claim 13 wherein the mixing means comprises a plurality of static mixer barriers forming partial walls disposed within the enclosed passageway.
16. The apparatus of claim 15 wherein the steam injected by the second injector inlet has a temperature of about 300° F. to about 500° F. and a pressure of about 90 to 150 psi.
17. The apparatus of claim 15 wherein the heated feed produced by the static mixer body has a temperature of about 190° F.
18. The apparatus of claim 13 further comprising a steam flow control valve to control a rate of the steam flow into the chamber and a first temperature transmitter disposed to measure a temperature of the heated feed exiting the static mixer body, wherein the injector body, the static mixer body, the steam flow control valve and the first temperature transmitter form a first closed loop control system, the steam flow control valve being responsive to the measured temperature of the heated feed by the first temperature transmitter.
19. The apparatus of claim 18 further comprising a steam flow pressure control valve to control a pressure of the steam flow into the chamber and a pressure transmitter disposed to measure the pressure of the steam flow from the pressure control valve, wherein the injector body, the static mixer body, the steam flow control valve, the temperature transmitter, the steam flow pressure control valve and the pressure transmitter form a second closed loop control system, the steam flow pressure control valve being responsive to the measured pressure.
20. The apparatus of claim 19 further comprising a condensate flow control valve to control the supply of a condensate to the steam for modulating the temperature of the steam for injecting by the second injector inlet and a second temperature transmitter disposed to measure the temperature of the steam supplied to the second injector inlet, wherein the injector body, the static mixer body, the steam flow control valve, the first temperature transmitter, the steam flow pressure control valve, the pressure transmitter, the condensate flow control valve, and the second temperature transmitter form a third closed loop control system, the condensate flow control valve being responsive to the temperature of the steam measured by the second temperature transmitter.
21. The apparatus of claim 13 wherein the mixing means comprises a baffle disposed across the enclosed passageway.
22. The apparatus of claim 13 wherein the steam supplied to the second injector inlet comprises saturated steam.
FIELD OF THE INVENTION
This invention relates to bitumen processing and more particularly is related to heating bituminous froth using inline steam injection.
BACKGROUND TO THE INVENTION
In extracting bitumen hydrocarbons from tar sands, one extraction process separates bitumen from the sand ore in which it is found using an ore washing process generally referred to as the Clark hot water flotation method. In this process, a bitumen froth is typically recovered at about 150° F. and contains residual air from the flotation process. Consequently, the froth produced from the Clark hot water flotation method is usually described as aerated bitumen froth. Aerated bitumen froth at 150° F. is difficult to work with. It has similar properties to roofing tar. It is very viscous and does not readily accept heat. Traditionally, processing of aerated bitumen froth requires the froth to be heated to 190° to 200° F. and deaerated before it can move to the next stage of the process.
Heretofore, the aerated bitumen froth is heated and de-aerated in large atmospheric tanks with the bitumen fed in near the top of the vessel and discharged onto a shed deck. The steam is injected below the shed deck and migrates upward, transferring heat and stripping air from the bitumen as they contact. The method works but much of the steam is wasted and bitumen droplets are often carried by the exiting steam and deposited on nearby vehicles, facilities and equipment.
SUMMARY OF THE INVENTION
The invention provides an inline steam heater to supply heated steam to a bitumen froth by direct contact of the steam to the bitumen froth resulting in superior in efficiency and environmental friendliness than processes heretofore employed.
In one of its aspect, the invention provides an inline bitumen froth steam heater system including at least one steam injection stage, each steam injection stage followed by a mixing stage. Preferably, the mixing stage obtains a mixing action using static mixing devices, for example, using baffle partitions in a pipe. In operation, the invention heats the bitumen froth and facilitates froth deaeration by elevating the froth temperature. In operation the bitumen froth heating is preferably obtained without creating downstream problems such as emulsification or live steam entrainment. The froth heater is a multistage unit that injects and thoroughly mixes the steam with bitumen resulting in solution at homogenous temperature. Steam heated to 300 degrees Fahrenheit is injected directly into a bitumen froth flowing in a pipeline where initial contact takes place. The two incompatible substances are then forced through a series of static mixers, causing the steam to contact the froth. The mixer surface area and rotating action of the material flowing through the static mixer breaks the components up into smaller particles, increasing contact area and allowing the steam to condense and transfer its heat to the froth. The reduction in bitumen viscosity also allows the release of entrapped air.
Other objects, features and advantages of the present invention will be apparent from the accompanying drawings, and from the detailed description that follows below. As will be appreciated, the invention is capable of other and different embodiments, and its several details are capable of modifications in various respects, all without departing from the invention. Accordingly, the drawings and description of the preferred embodiments are illustrative in nature and not restrictive
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a functional block diagram of a preferred embodiment of a bitumen froth heating process arrangement of the invention.
FIG. 2 is a cross section elevation view of an inline steam heater and mixer stage of FIG. 1.
FIG. 2 a is an elevation view of a baffle plate of FIG. 2.
DETAILED DESCRIPTION OF THE INVENTION
In accordance with a preferred embodiment of the process two inputs components, namely, bitumen froth and steam, are contacted to produce an output homogenous bitumen product heated to a temperature of 190° F. The input bitumen froth component 10 is supplied at about 150° F. In a pilot plant implementation the input bitumen froth component is supplied via a 28 inch pipeline at a rate of about 10,000 barrels per hour. The input steam component 12 is supplied as a superheated steam at about 500° F. and at 150 psi.
FIG. 1 shows a functional block diagram of a preferred embodiment of a bitumen froth heating apparatus arranged in accordance with the invention. The input steam component 12 is supplied to a pressure control valve 14 which reduces the pressure to a set point pressure, which is typically about 90 psi. A pressure transmitter 16 is provided to monitor the pressure of the steam downstream from the pressure control valve 14 to provide a closed loop control mechanism to control the pressure of the steam at the set point pressure. The pressure controlled steam is supplied to a temperature control valve 18 that is used to control the supply of condensate 20 to cool the steam to its saturation point, which is about 300° F. at the controlled pressure of 90 psi. A temperature sensor 22 monitors the steam temperature downstream from the temperature control valve to provide a closed loop control mechanism to control the temperature of the steam at the temperature set point setting.
The optimum parameters for steam injection vary so a computer 24 executes a compensation program to review the instantaneously supplied instrumentation pressure 26 and temperature 28 measurements and adjusts inlet steam pressure and temperature set point settings as required. A pressure sensor 29 measures the pressure of the input bitumen component 10 to provide the compensation program executing on computer 24 with this parameter to facilitate optimum control of the parameters for steam injection.
To provide a greater capacity for supply or transfer of heat to the bitumen froth component, the pressure and temperature controlled steam 30 is split into two steam sub-streams 30 a, 30 b. Each steam sub-stream is supplied to a respective steam injector 32 a, 32 b and the steam injectors 32 a and 32 b are arranged in series to supply heat to the bitumen froth component stream 10. While two steam injectors arranged in series are shown in the figure, it will be understood that the bitumen froth component stream 10 could equally well be split into two sub-streams and each bitumen froth component sub-stream supplied to a respective steam injector arranged in parallel. Moreover, it will be understood that more than two sub-streams of either the steam component or the bitumen component streams could be provided if process flow rates require. A suitable inline steam injector 32 a, 32 b is manufactured by Komax Systems Inc. located in Calif., USA.
An inline steam injection heater works well in heating water compatible fluids but bitumen is not water compatible so additional mixing is advantageous to achieve uniform fluid temperature. Consequently, in the preferred embodiment depicted in FIG. 1, the bitumen and steam material flow mixture is passed through an inlet baffle 34 a, 34 b downstream from the respective steam injector 32 a, 32 b. The inlet baffle, which is shown more clearly in FIG. 2 a, directs the material flow mixture downward to initiate the mixing action of the steam component with the bitumen froth component. Mixing of the material flow continues by passing the material flow through static mixers 36 a and 36 b respectively.
As seen most clearly in FIG. 2, the static mixers provide baffles 40 arranged along the interior volume of each static mixer to effect a mixing action of the material flowing through the static mixer. The mixing action of the material flow through the static mixer is provided by arranging the baffles 40 within the static mixer to impart a lateral, radial, tangential and/or circumferential directional component to the material flow that changes repeatedly along the length of the static mixer. Different static mixer designs and baffle arrangements may be used to advantage in mixing the steam component with the bitumen froth component.
A temperature transmitter 42 is located downstream of the mixers 36. The temperature of the material flow exiting the static mixer is measured by the temperature transmitter 42 and is used to control the rate of supply of steam to the inline steam injector 32 by the associated flow control valve 44. In this manner, a closed loop control system is provided to control the supply of the steam component to the bitumen froth component to obtain a set point or target output temperature of the material flow leaving the static mixer 36.
Referring again to FIG. 1, the heating system shown in FIG. 2 is arranged with a temperature transmitter 42 a, 42 b located downstream of each respective mixer 36 a, 36 b. The temperature of the material exiting each static mixer is measured by the temperature transmitter and is used to control the rate of supply of steam to the inline steam injectors 32 a, 32 b by the associated flow control valve 44 a, 44 b respectively. In this manner, a closed loop control system is provided to control the supply of the steam component to the bitumen froth component to obtain a set point or target output temperature of the material flow leaving each static mixer stage 36 a, 36 b. The water content of the bitumen froth component 10 can range form 30% to 50%. In a pilot plant implementation of the preferred embodiment, each inline steam heater 32 a, 32 b was found to be capable of heating about 10,000 barrels per hour of bitumen froth by about 30° F. utilizing about 80,000 pounds per hour of steam. By way of comparison to conventional process apparatus, the atmospheric tank method would use about 125,000 pounds of steam to achieve a similar heat transfer.
After heating, the heated bitumen froth is delivered to a plant for processing. To facilitate material flow rate co-ordination with the processing plant, the heated bitumen froth may be discharged to a downstream holding tank 46, preferably above the liquid level 48. The heated, mixed bitumen froth releases entrained air, preferably, therefore, the holding tank is provided with a vent 50 to disperse the entrapped air released from the bitumen froth. To maintain the temperature of the heated bitumen froth in the holding tank 46, a pump 50 and recycle line 52 are provided, which operate to recycle the hot bitumen froth from the holding tank to the process inlet of the heaters.
The invention has been described with reference to preferred embodiments. Those skilled in the art will perceive improvements, changes, and modifications. The scope of the invention including such improvements, changes and modifications is defined by the appended claims.
| Patente citada|| Fecha de presentación|| Fecha de publicación|| Solicitante|| Título|
|US685895||29 Ago 1900||5 Nov 1901||Ernst Wirth||Process of purifying anthracene.|
|US1590156||27 Mar 1924||22 Jun 1926||Ellis Foster Co||Process of treating wood tar oil|
|US1598973||27 Nov 1925||7 Sep 1926||Kolsky George||Art of treating oils|
|US2052881||18 May 1935||1 Sep 1936||Calco Chemical Co Inc||Purification of alcohols|
|US2236796||13 Sep 1938||1 Abr 1941||Kipper Herman B||Process for the synthesis of chlorinated saturated and unsaturated hydrocarbon oils|
|US2734019||22 Abr 1953||7 Feb 1956|| ||Hydrofining naphthenic lubricating oil|
|US2847353||30 Dic 1955||12 Ago 1958||Texas Co||Treatment of residual asphaltic oils with light hydrocarbons|
|US2910424||19 Nov 1956||27 Oct 1959||Phillips Petroleum Co||Separation and recovery of oil from oil sands|
|US2921023||14 May 1957||12 Ene 1960||Pure Oil Co||Removal of naphthenic acids by hydrogenation with a molybdenum oxidesilica alumina catalyst|
|US3159562 *||7 Sep 1961||1 Dic 1964||Exxon Research Engineering Co||Integrated process for effectively recovering oil from tar sands|
|US3509641 *||17 May 1968||5 May 1970||Great Canadian Oil Sands||Tar sands conditioning vessel|
|US3594201||29 Abr 1968||20 Jul 1971||Shell Oil Co||Asphalt emulsions|
|US3617530||12 Nov 1969||2 Nov 1971||Atlantic Richfield Co||Metals removal from heavy hydrocarbon fractions|
|US3798157||10 May 1973||19 Mar 1974||Mexicano Inst Petrol||Process for the removal of contaminants from hydrocracking feedstocks|
|US3807090||6 Dic 1972||30 Abr 1974||Exxon Research Engineering Co||Purifications of fuels|
|US3808120||9 Jul 1973||30 Abr 1974||Atlantic Richfield Co||Tar sands bitumen froth treatment|
|US3876532||27 Feb 1973||8 Abr 1975||Gulf Research Development Co||Method for reducing the total acid number of a middle distillate oil|
|US3893907||10 Sep 1973||8 Jul 1975||Exxon Research Engineering Co||Method and apparatus for the treatment of tar sand froth|
|US3967777||27 Nov 1974||6 Jul 1976||Exxon Research And Engineering Company||Apparatus for the treatment of tar sand froth|
|US3971718||9 Jul 1974||27 Jul 1976||Elast-O-Cor Products & Engineering Limited||Hydrocyclone separator or classifier|
|US3998702 *||14 Oct 1975||21 Dic 1976||Great Canadian Oil Sands Limited||Apparatus for processing bituminous froth|
|US4033853 *||16 Ene 1976||5 Jul 1977||Great Canadian Oil Sands Limited||Process and apparatus for heating and deaerating raw bituminous froth|
|US4035282||20 Ago 1975||12 Jul 1977||Shell Canada Limited||Process for recovery of bitumen from a bituminous froth|
|US4072609||10 Feb 1977||7 Feb 1978||Canada-Cities Service, Ltd.||Capacitance system for heavy phase discharge of second stage centrifugal separation circuit|
|US4101333||23 May 1977||18 Jul 1978||Joy Manufacturing Company||Method of mine backfilling and material therefor|
|US4116809||2 Dic 1976||26 Sep 1978||Canada-Cities Service, Ltd.||Deaerator circuit for bitumen froth|
|US4120776||29 Ago 1977||17 Oct 1978||University Of Utah||Separation of bitumen from dry tar sands|
|US4172025||11 May 1978||23 Oct 1979||Canada-Cities Service, Ltd.||Process for secondary recovery of bitumen in hot water extraction of tar sand|
|US4279743||15 Nov 1979||21 Jul 1981||University Of Utah||Air-sparged hydrocyclone and method|
|US4305733||6 Mar 1980||15 Dic 1981||Linde Ag||Method of treating natural gas to obtain a methane rich fuel gas|
|US4337143||2 Jun 1980||29 Jun 1982||University Of Utah||Process for obtaining products from tar sand|
|US4383914||18 May 1981||17 May 1983||Canada-Cities Service, Ltd.||Dilution centrifuging of bitumen froth from the hot water process for tar sand|
|US4397741||20 Nov 1981||9 Ago 1983||University Of Utah||Apparatus and method for separating particles from a fluid suspension|
|US4399027||29 Ago 1980||16 Ago 1983||University Of Utah Research Foundation||Flotation apparatus and method for achieving flotation in a centrifugal field|
|US4399112||21 Abr 1981||16 Ago 1983||Societe Nationale Elf Aquitaine||Process for the catalytic incineration of residual gases containing a low content of at least one sulfur compound selected from COS, CS.sub.2 and the mercaptans and possibility at least one member of the group|
|US4409090||1 Feb 1982||11 Oct 1983||University Of Utah||Process for recovering products from tar sand|
|US4410417||6 Oct 1980||18 Oct 1983||University Of Utah Research Foundation||Process for separating high viscosity bitumen from tar sands|
|US4424113 *||7 Jul 1983||3 Ene 1984||Mobil Oil Corporation||Processing of tar sands|
|US4437998||23 Abr 1982||20 Mar 1984||Suncor, Inc.||Method for treating oil sands extraction plant tailings|
|US4462892||17 Mar 1983||31 Jul 1984||Alberta Energy Company Ltd.||Control of process aid used in hot water process for extraction of bitumen from tar sand|
|US4470899||14 Feb 1983||11 Sep 1984||University Of Utah||Bitumen recovery from tar sands|
|US4486294||17 Oct 1983||4 Dic 1984||University Of Utah||Process for separating high viscosity bitumen from tar sands|
|US4502950||31 Ene 1984||5 Mar 1985||Nippon Oil Co., Ltd.||Process for the solvent deasphalting of asphaltene-containing hydrocarbons|
|US4514287||30 Dic 1982||30 Abr 1985||Nippon Oil Co., Ltd.||Process for the solvent deasphalting of asphaltene-containing hydrocarbons|
|US4514305||1 Dic 1982||30 Abr 1985||Petro-Canada Exploration, Inc.||Azeotropic dehydration process for treating bituminous froth|
|US4525155||11 Abr 1984||25 Jun 1985||Alfa-Laval Marine And Powering Engineering Ab||Centrifugal separator and method of operating the same|
|US4525269||3 May 1984||25 Jun 1985||Nippon Oil Co., Ltd.||Process for the solvent deasphalting of asphaltene-containing hydrocarbons|
|US4528100||31 Oct 1983||9 Jul 1985||General Electric Company||Process for producing high yield of gas turbine fuel from residual oil|
|US4532024||3 Dic 1984||30 Jul 1985||The Dow Chemical Company||Process for recovery of solvent from tar sand bitumen|
|US4545892||15 Abr 1985||8 Oct 1985||Alberta Energy Company Ltd.||Treatment of primary tailings and middlings from the hot water extraction process for recovering bitumen from tar sand|
|US4581142||11 Ene 1984||8 Abr 1986||Titech, Joh. H. Andresen||Hydrocyclone|
|US4585180||29 Jun 1984||29 Abr 1986||Alan Potts||Mineral breakers|
|US4604988||19 Mar 1984||12 Ago 1986||Budra Research Ltd.||Liquid vortex gas contactor|
|US4634519||11 Jun 1985||6 Ene 1987||Chevron Research Company||Process for removing naphthenic acids from petroleum distillates|
|US4677074||21 Jun 1984||30 Jun 1987||The Lubrizol Corporation||Process for reducing sulfur-containing contaminants in sulfonated hydrocarbons|
|US4733828||30 Ene 1987||29 Mar 1988||Mmd Design & Consultancy Limited||Mineral breaker|
|US4744890||21 Mar 1986||17 May 1988||University Of Utah||Flotation apparatus and method|
|US4781331||15 Oct 1987||1 Nov 1988||Alan Potts||Mineral breaker|
|US4783268||28 Dic 1987||8 Nov 1988||Alberta Energy Company, Ltd.||Microbubble flotation process for the separation of bitumen from an oil sands slurry|
|US4799627||16 Ene 1987||24 Ene 1989||Mmd Design And Consultancy Limited||Mineral sizers|
|US4828393||9 Mar 1987||9 May 1989||501 B.V. Grint||Method for obtaining a base material for building mortar|
|US4838434||17 May 1988||13 Jun 1989||University Of Utah||Air sparged hydrocyclone flotation apparatus and methods for separating particles from a particulate suspension|
|US4851123||20 Nov 1986||25 Jul 1989||Tetra Resources, Inc.||Separation process for treatment of oily sludge|
|US4859317||1 Feb 1988||22 Ago 1989||Shelfantook William E||Purification process for bitumen froth|
|US4915819||9 Sep 1988||10 Abr 1990||Intevep Sa||Treatment of viscous crude oils|
|US4981579||2 Dic 1988||1 Ene 1991||The Standard Oil Company||Process for separating extractable organic material from compositions comprising said extractable organic material intermixed with solids and water|
|US4994097||27 Sep 1989||19 Feb 1991||B. B. Romico B.V. I.O.||Rotational particle separator|
|US5009773||7 Ene 1987||23 Abr 1991||Alberta Energy Company Ltd.||Monitoring surfactant content to control hot water process for tar sand|
|US5017281||30 May 1989||21 May 1991||Tar Sands Energy Ltd.||Treatment of carbonaceous materials|
|US5032275||20 Nov 1987||16 Jul 1991||Conoco Specialty Products Inc.||Cyclone separator|
|US5039398||19 Mar 1990||13 Ago 1991||Uop||Elimination of caustic prewash in the fixed bed sweetening of high naphthenic acids hydrocarbons|
|US5055202||16 Nov 1988||8 Oct 1991||Conoco Specialty Products Inc.||Method and apparatus for maintaining predetermined cyclone separation efficiency|
|US5073177||15 Oct 1990||17 Dic 1991||B.B. Romico B.V. I.O.||Rotational particle separator|
|US5092983||30 Nov 1989||3 Mar 1992||The Standard Oil Company||Process for separating extractable organic material from compositions comprising said extractable organic material intermixed with solids and water using a solvent mixture|
|US5118408||6 Sep 1991||2 Jun 1992||Alberta Energy Company, Limited||Reducing the water and solids contents of bitumen froth moving through the launder of a spontaneous flotation vessel|
|US5124008||22 Jun 1990||23 Jun 1992||Solv-Ex Corporation||Method of extraction of valuable minerals and precious metals from oil sands ore bodies and other related ore bodies|
|US5143598||14 Ene 1988||1 Sep 1992||Amoco Corporation||Methods of tar sand bitumen recovery|
|US5156751||29 Mar 1991||20 Oct 1992||Miller Neal J||Three stage centrifuge and method for separating water and solids from petroleum products|
|US5186820||4 Dic 1991||16 Feb 1993||University Of Alabama||Process for separating bitumen from tar sands|
|US5207805||27 Mar 1992||4 May 1993||Emtrol Corporation||Cyclone separator system|
|US5223148||12 Nov 1991||29 Jun 1993||Oslo Alberta Limited||Process for increasing the bitumen content of oil sands froth|
|US5236577||2 Mar 1992||17 Ago 1993||Oslo Alberta Limited||Process for separation of hydrocarbon from tar sands froth|
|US5242580||2 Mar 1992||7 Sep 1993||Esso Resources Canada Limited||Recovery of hydrocarbons from hydrocarbon contaminated sludge|
|US5242604||10 Ene 1992||7 Sep 1993||Sudden Service Co.||Lateral flow coalescing multiphase plate separator|
|US5264118||26 Dic 1991||23 Nov 1993||Alberta Energy Company, Ltd.||Pipeline conditioning process for mined oil-sand|
|US5295350||26 Jun 1992||22 Mar 1994||Texaco Inc.||Combined power cycle with liquefied natural gas (LNG) and synthesis or fuel gas|
|US5316664||23 Oct 1992||31 May 1994||Canadian Occidental Petroleum, Ltd.||Process for recovery of hydrocarbons and rejection of sand|
|US5340467||24 Oct 1991||23 Ago 1994||Canadian Occidental Petroleum Ltd.||Process for recovery of hydrocarbons and rejection of sand|
|US5480566||27 Nov 1991||2 Ene 1996||Bitmin Corporation||Method for releasing and separating oil from oil sands|
|US5538539||20 Ene 1995||23 Jul 1996||Wahlco, Inc.||Catalytic sulfur trioxide flue gas conditioning|
|US5540755||12 Sep 1995||30 Jul 1996||Wahlco, Inc||Catalytic sulfur trioxide flue gas conditioning|
|US5581864||4 May 1995||10 Dic 1996||Suncor, Inc.||Coke drum deheading system|
|US5626191||23 Jun 1995||6 May 1997||Petroleum Recovery Institute||Oilfield in-situ combustion process|
|US5645714||3 May 1995||8 Jul 1997||Bitman Resources Inc.||Oil sand extraction process|
|US5667543||15 Abr 1994||16 Sep 1997||Romico Hold A.V.V.||Rotating particle separator with non-parallel separating ducts, and a separating unit|
|US5723042||17 Oct 1996||3 Mar 1998||Bitmin Resources Inc.||Oil sand extraction process|
|US5740834||2 Ago 1996||21 Abr 1998||Exxon Research And Engineering Company||Reverse angle integrally counter-weighted trickle valve|
|US5798087||10 Dic 1996||25 Ago 1998||Kansai Electric Power Co., Inc.||Method of producing gypsum|
|US5820750||17 Ene 1997||13 Oct 1998||Exxon Research And Engineering Company||Thermal decomposition of naphthenic acids|
|US5876592||18 May 1995||2 Mar 1999||Alberta Energy Co., Ltd.||Solvent process for bitumen separation from oil sands froth|
|US5897769||29 Ago 1997||27 Abr 1999||Exxon Research And Engineering Co.||Process for selectively removing lower molecular weight naphthenic acids from acidic crudes|
|US5910242||29 Ago 1997||8 Jun 1999||Exxon Research And Engineering Company||Process for reduction of total acid number in crude oil|
|US5928501||3 Feb 1998||27 Jul 1999||Texaco Inc.||Process for upgrading a hydrocarbon oil|
|US5961821||27 Mar 1998||5 Oct 1999||Exxon Research And Engineering Co||Removal of naphthenic acids in crude oils and distillates|
|US6007709 *||31 Dic 1997||28 Dic 1999||Bhp Minerals International Inc.||Extraction of bitumen from bitumen froth generated from tar sands|
|US6391190 *||4 Mar 1999||21 May 2002||Aec Oil Sands, L.P.||Mechanical deaeration of bituminous froth|
|US6800116 *||18 Jul 2002||5 Oct 2004||Suncor Energy Inc.||Static deaeration conditioner for processing of bitumen froth|
|1||Alberta Oil History, An Interview with Roger Butler, vol. 2 Issue 2, pp. 33-35.|
|2||Al-Shamali and Greaves, "In Situ Combustion (ISC) Processes: Enhances Oil Recovery Using Horizontal Wells", School of Chemical Engineering, University of Bath, UK, Trans IChemE, vol. 71, Part A, May 1993, pp. 345-346.|
|3||Bagci and Shamsul, "A Comparison of Dry Forward Combusion with Diverse Well Configurations in a 3-D Physical Model Using Medium and Low Gravity Crudes", Middle East Technical University (10 pages).|
|4||Bratsch and lagowski, On the Existence of Na in Liquid Ammonia, 1984 American Chemical Society, 1086-1089 pp. 1086-1089.|
|5||Collison, "Hot About Thai: A Calgary company researches a step-change in bitumen recovery technology", Oilweek Mar. 1, 2004, pp. 42-46.|
|6||District 5 CIM Conference, Presentation slides "Identification and Treatment of Weathered Ores at Suncor's Steepbank Mine", Jun. 14, 2001, Alberta, Canada.|
|7||European Commission, European Symposium on Heavy Oil Technologies in a Wider Europe, A Therme Programme Action Berlin, Jun. 7 & 8, 1994, Greaves, Wang and Al-Shamali, "Insitu Combustion (ISC) Processes: 3D Studies of Vertical and Horizontal Wells", IOR Research Group, School of Chemical Engineering, University of Bath, UK.|
|8||Eva Mondt "Compact Centrifugal Separator of Dispersed Phases" Proefschrift.|
|9||Fenske, McCormick, Lawroski, and Geier, "Extraction of Petroleum Fractions by Ammonia Solvents", E.I.Ch.E. Journal, vol. 1. No. 3. pp. 335-341.|
|10||Greaves, Tuwil and Bagci, "Horizontal Producer Wells in in Situ Combustion (ISC) Process", The Journal of Canadian Petroleum Technology, Apr. 1993, vol. 32, No. 4, pp. 58-67.|
|11||IEO 1997 World Oil Markets "The World Oil Market" pp. 1-19.|
|12||Industry Statistics "Monthly Petroleum Facts at a Glance" Jan. 2002 pp. 1-2.|
|13||Jones and Goldstein "The SkyMine Process", Skyonic Corporation Sep. 20, 2005.|
|14||Keller, Noble and Caffey "A Unique, Reagent-Based, Separation Method for Tar Sands and Environmentall Clean Ups" Presented to AIChE 2001 Annual Meeting Nov. 6, 2001 Reno, Nevada.|
|15||Krebs' Engineers, Krebs D-Series gMAX DeSanders for Oil and Gas, Bulletin 11-203WEL.|
|16||Lagowski, Liquid Ammonia-A Unique Solvent, Chemistry vol. 41, No. 4, pp. 10-15.|
|17||Lemley, Roberts, Plowman and Lagowski, Liquid Ammonia Solutions. X. A Raman Study of Interactions in the Liquid State, The Journal of Physical Chemistry vol. 77 No. 18, 1973 pp. 2185-2191.|
|18||Miner's Toolbox, Mine Backfill Engineering, 2000-2005.|
|19||Minespace 2001, Presentation slides "Identification ad Treatment of Weathered Ores at Suncor's Steepbank Mine", May 2, 2001, Quebec City, Canada.|
|20||Natural Resources Canada, Treatment of Bitumen Froth and Slop Oil Tailings, National Energy Board, Canada's Oil Sands: A Supply and Market Outlook to 2015, An Energy Market Assessment Oct. 2000.|
|21||New Logic Research, Using V SEP to Treat Desalter Effluent, Case Study Copyright 2003 9 pages.|
|22||Rimmer, Gregoli and Yildlrim, "Hydrocyclone-based Process for Rejecting Solids from Oil Sands at the Mine Site While Retaining Bitumen for Transportation to a Processing Plant"; Suncor Extraction 3rd fl pp. 93-100, Paper delivered on Monday Apr. 5, 1993 at a conference in Alberta, Canada entitled "Oil Sands-Our Petroleum Future".|
|23||Schramm et al. "Some Observations on the Aging Phenomenon in the Hot Water Processing of Athabasca Oil Sands. Part 1-The Nature of the Phenomenom", AOSTRA J. Res., 3 (1987) 195-214.|
|24||Schramm et al. "Some Observations on the Aging Phenomenon in the Hot Water Processing of Athabasca Oil Sands. Part 2-The Mechanism of Aging", AOSTRA J. Res., 3 (1987) 215-224.|
|25||Schramm et al. "Two Classes of Anionic Surfactants and Their Significance in Hot Water Processing of Oil Sands", Can. J. Chem. Eng., 65 (1987) 799-811.|
|26||Schramm, Smith and Stone "The Influence of Natural Surfactant Concentration on the Hot Water Process for Recovering Bitumen from the Athabasca Oil Sands" AOSTRA Journal of Research, vol. 1, 1984 pp. 5-13.|
|27||The Fine Tailings Fundamentals Consortium "Advances in Oil Sands Tailings Research" ISBN 0-7732-1691-X Published by Alberta Department of Energy Jun. 1995.|
|28||Wallace et al. "A Physical Chemical Explanation for Deterioration in the Hot Water Processability of Athabasca Oil Sand Due to Aging", Fuel Sci. Technol. Int., 7 (1989) 699-725.|
| Patente citante|| Fecha de presentación|| Fecha de publicación|| Solicitante|| Título|
|US7677397||25 Jul 2005||16 Mar 2010||Suncor Energy Inc.||Sizing roller screen ore processing apparatus|
|US8136672||23 Dic 2009||20 Mar 2012||Suncor Energy, Inc.||Sizing roller screen ore processing apparatus|
|US8328126||18 Sep 2009||11 Dic 2012||Suncor Energy, Inc.||Method and apparatus for processing an ore feed|
|US8357291||19 Dic 2008||22 Ene 2013||Exxonmobil Upstream Research Company||Upgrading bitumen in a paraffinic froth treatment process|
|US8622326||24 Oct 2011||7 Ene 2014||Suncor Energy, Inc.||Method and apparatus for processing an ore feed|
|US20110174592 *||28 Mar 2011||21 Jul 2011||Suncor Energy Inc.||Bituminous froth inline steam injection processing|
| || |
| Clasificación de EE.UU.||196/14.52, 366/101, 95/262, 208/391, 209/12.1, 208/390|
| Clasificación internacional||B01D11/00, C10G1/02, B01F13/02, B03B9/02, C10C3/00, C10G1/04|
| Clasificación cooperativa||C10G2300/807, C10G1/02|
| Clasificación europea||C10G1/02|
|28 Dic 2012||FPAY||Fee payment|
Year of fee payment: 4
|16 Abr 2004||AS||Assignment|
Owner name: SUNCOR ENERGY INC., CANADA
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:GASTON, LES;MADGE, DONALD NORMAN;STRAND, WILLIAM LESTER;AND OTHERS;REEL/FRAME:015224/0523;SIGNING DATES FROM 20040116 TO 20040121